Alternative Proposal for Discussion October 27, 2015 Update Since - - PowerPoint PPT Presentation

Proposal for Discussion October 27, 2015

PDR Energy Baseline Alternative

• Since the October 12th Working Group Meeting Stem, Solar

City, AMS and CESA have had over a half-dozen meetings to discuss adjustments to the CAISO’s proposed methods for estimating generation output used for retial purposes.

• We concluded that the CAISO’s proposed option titled “using

a baseline” that calculates a Gtadjusted value is the most viable

• ption if we must move forward quickly.
• Similar to the CAISO’s Gtadjusted construct, we propose

establishing a “typical-usage level” (GTYPICAL) based on electric

• utput using (G) metered quantities during non-dispatch days.
• We recommend moving forward with a Gtadjusted calculation,

while also continuing to discuss broader issues around dual- use in Phase II of the CAISO’s ESDER Initiative.

Update Since Last Meeting

Background | Why do we need a change?

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• In its recent Local Capacity Resource Procurement, SCE signed

PPAs for 135 of Demand Response Energy Storage (DRES) Resources - 85 MW with Stem, 50 MW with AMS.

• Projects are being installed now, with testing occurring in the

second half of 2015 and commercial operation dates of 10/1/2016.

• AMS contracts require use of an energy baseline unless there

is a CAISO approved alternative.

• Resources are designed to be dispatched often, making use of

the PDR baseline / collecting 10 days of accurate load data on non-event days could be challenging during certain times of the year.

Alternative Baseline| Use Case

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• Location: Behind-the-Meter C&I installation
• Product: Load drop to an IOU ~100 times a year using DR

and/or battery storage

• Value Streams:

– Wholesale: Contractual dispatches by IOU – Retail: Energy arbitrage, demand charge management, retail demand response programs

Alternative Baseline| Proposal Overview

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• Similar to the CAISO’s Gtadjusted construct, establish a “typical-usage level” (GTYPICAL)

based on electric output using (G) metered quantities during non-dispatch days.

• Days would be selected by conducting a look back of comparable, non-dispatch

days (similar to the CAISO’s existing 10-in-10 in 45 baseline methodology for loads).

• Scenario A: Similar to the PDR baseline methodology, the first 10 non-event similar

day-type days are selected. A non-event day is a day in which no hour contains a PDR dispatch. A profile is created by averaging 5-minute data to the hour and then

• ver the 10 days. Performance (P) during each interval (t) during the PDR call is

therefore: P = - (G - GTYPICAL).

• Scenario B: If 10 non-event days cannot be found within a look-back window, then

the resource is deemed to be a full-time market participant and GTYPICAL = 0 and the resource receives credit for the full generation value during the event duration (standard proposed PDR rules for MGO).

Use the battery meter to directly measure/settle contractual dispatches; with an adjustment calculating out typical retail use.

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• 250

250 500 750 1000

0:00 2:00 4:00 6:00 8:00 10:0012:0014:0016:0018:0020:0022:00

Energy (kWh) Performance with 10-day Adjustment on MGO

Facility load (kW) Site meter (kW) Performance, G_adj (kW) MGO adjustment

Average of 10 non-event days over past 45 days Sept 22, 2014 Dispatch, 10 Prior Workdays for Adjustment Calculation

MGO Hour-Specific Adjustment Method

18% adjustment

Dispatch

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Meter 9/8 9/9 9/10 9/11 9/12 N 723 kW 723 kW 723 kW 719 kW 723 kW G

• 28 kW
• 28 kW
• 15 kW
• 8 kW
• 27 kW

L 751 kW 751 kW 738 kW 727 kW 751 kW

Measurements at HE 15:00 in kW

Meter 9/15 9/16 9/17 9/18 9/19 N 723 kW 723 kW 723 kW 723 kW 723 kW G

• 127 kW
• 66 kW
• 50 kW
• 21 kW

0 kW L 851 kW 789 kW 773 kW 743 kW 700 kW Meter Dispatch Day: 9/22 N 543 kW G

• 211 kW

G_typical

• 37 kW

L 754 kW P = -(G - G_typical) 174 kW

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Alternative Baseline | Likely Dispatch

Oct-14 Nov-14 Dec-14 Jan-15 Feb-15 Mar-15 Apr-15 May-15 Jun-15 Jul-15 Aug-15 Sep-15

• n peak

36.49 34.93 79.92 56.98 51.73 34.31 34.52 33.48 36.95 32.02 35.29 38.3

• ff peak

37.22 35.52 71.53 57.54 54.06 35.4 34.79 33.97 37.59 32.4 36.04 39.15 Dispatch Days 23 20 21 22 11

Net Benefits Test Prices ($/MWh) and Workdays with LMP Above On Peak Price

Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 Mar-14 Apr-14 May-14 Jun-14 Jul-14 Aug-14 Sep-14

• n peak

52.4 50.15 42.8 56.63 65.57 79.43 71.51 65.35 56.08 55.57 62.97 58.45

• ff peak

56.16 51.62 43.54 57.42 66.23 80.26 72.79 67.86 61.95 64.09 64.38 64.21 Dispatch Days 1 4 22 8 11 1 Oct-12 Nov-12 Dec-12 Jan-13 Feb-13 Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13

• n peak

31.87 39.44 40.53 37.25 37.18 38.05 41.63 45.93 48.6 47.79 44.64 41.35

• ff peak

32.13 39.38 41.14 38.06 37.98 39.23 42.66 48.21 49.9 51.46 48.22 42.19 Dispatch Days 23 15 12 23 20 21 22 13 6 8 9 16

Additional Slides (If Needed)

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Most Recent 10 Days without Dispatch

February 17-28, 2014: one week has 4 days of peak shaving

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Two Previous Weeks: No Peak Shaving